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This report presents the results of an analysis evaluating the economic viability of hydrogen for medium- to large-scale electrical energy storage applications compared with three other storage technologies: batteries, pumped hydro, and compressed air energy storage (CAES).
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![Figure 1. Schematic of the constant-pressure PHCA [4].](publication/350584119/figure/fig1/AS:1008127566704640@1617367750172/Schematic-of-the-constant-pressure-PHCA-4_Q320.jpg)
![Main parameters and their values of constant-pressure PHCA system [4].](publication/350584119/figure/tbl1/AS:1008127566680064@1617367750218/Main-parameters-and-their-values-of-constant-pressure-PHCA-system-4_Q320.jpg)
Citations
... We use the data from NREL ATB report (Akar et al, 2020) for battery storage costs. Cost assumptions for hydrogen storage consider charging, discharging, and storage, with cost projections for charging capacity (electrolysis) and fixed O&M for 2045 projected out from 2030 (Saba et al, 2018;Steward et al, 2009) and ...
Land-use conflicts may constrain the unprecedented rates of renewable energy deployment required to meet the decarbonization goals of the Inflation Reduction Act (IRA). This paper employs geospatially resolved data and a detailed electricity system capacity expansion model to generate 160 affordable, zero-carbon electricity supply portfolios for the American west and evaluates the land use impacts of each portfolio. Less than 4% of all sites suitable for solar development and 17% of all wind sites appear in this set of portfolios. Of these sites, 53% of solar and 85% of wind sites exhibit higher development risk and potential for land use conflict. We thus find that clean electricity goals cannot be achieved in an affordable manner without substantial renewable development on sites with potential for land use conflict. However, this paper identifies significant flexibility across western U.S. states to site renewable energy or alter the composition of the electricity supply portfolio to ameliorate potential conflicts.
... SOFC is the natural alternative in many heavy vehicle applications because of its ability to run on biogas, bioethanol, bio-methanol and syngas reformed hydrogen. CO as a fuel can be used on SOFCs, while CO is a poison to the PEMFC, which makes SOFC suitable for syngas and biofuels (figure-8) [3,[41][42][43][44][45][46][47][48][49][50][51][52]. ...
About 175 years have passed since the invention of the Fuel Cell by Schoenbein und Grove, however, fuel cell-based automobiles have received increased attention in the last few years due to growing public concern over urban air pollution and consequent environmental problems. Direct combustion of fuel for transportation accounts for over half of greenhouse gas emissions and a significant fraction of air pollutant emissions. Fuel cell power systems for automotive applications have the potential for high fuel efficiency and lower emissions. The energy demand depends greatly on driving characteristics, however from the power analysis and the power and energy requirements of a modern car, it is estimated that normal usage is expected to be 200 Wh/km. Hydrogen can be used in two ways to run Fuel Cells, firstly the fuel can be converted directly in the fuel cell, or it may be reformed to hydrogen to store on the vehicle.
... The three forms of fuzzy rule-based EMS are conventional fuzzy control, predictive fuzzy control, and adaptive fuzzy control [25]. Bathaee et al. [30] developed a fuzzy-based torque controller for parallel HEVs. The ICE operational points are determined by the required battery SOC and ICE torque. ...
Electric vehicles (EVs) are seen as a necessary component of transportation's future growth. However, the performance of batteries related to power density and energy density restricts the adoption of electric vehicles. To make the transition from a conventional car to a pure electric vehicle (PEV), a Hybrid Electric Vehicle's (HEV) Energy Management System (EMS) is crucial. The HEVs are often powered with hybrid electrical sources, therefore it is important to select the optimal power source to improve the HEV performance, minimize the fuel cost and minimize hydrocarbon and nitrogen oxides emission. This paper presents the Grey Wolf Optimization (GWO) algorithm for the control of the power sources in the HEVs based on power requirement and economy. The proposed GWO-based EMS provides optimized switching of the power sources and economical and pollution free control of HEV.
... Efficiencies and costs of the other wind-storage systems. Costs estimated from[49,50]. ...
The increasing push for renewable penetration into electricity grids will inevitably lead to an increased requirement for grid-scale energy storage at multiple time scales. It will, necessarily, lead to a higher proportion of the total energy consumed having been passed through storage. Offshore wind is a key technology for renewable penetration, and the co-location of energy storage with this wind power provides significant benefits. A novel generation-integrated energy storage system is described here in the form of a wind-driven air compressor feeding underwater compressed air energy storage. A direct drive compressor would require very high intake swept volumes. To overcome this difficulty, some prior compression is introduced. This paper discusses the constituent technologies for this concept, as well as the various configurations that it might take and the logic behind operating it. Special consideration has been given to the differences resulting from utilising a near-isothermal wind-driven compressor versus a near-adiabatic one. Multiple iterations of the system have been simulated. This has been done using a price-matching algorithm to optimise the system operation and using volumetric air flow rates to calculate exergy flow. Simulated operation has been performed for a year of real wind and electricity price data. This work has been performed in order to clarify the relationships between several key parameters in the system, including pressure and work ratios, volumetric flowrates, storage costs and profit rates. An additional objective of this paper was to determine whether the system has the potential for economic viability in some future energy grid, especially when compared with alternative wind and energy storage solutions. The results of the simulation indicated that, with proper sizing, the system might perform competitively with these alternatives. Maximum one-year return on investment values of 9.8% for the isothermal case and 13% for the adiabatic case were found. These maxima were reached with ~15–20 h of output storage. In all cases, it was found that maximising the power of the wind-driven compressor compared with the initial compressor was favourable.
... Energy required for compression [144] and any potential compression losses [145] are applied to the electrolyzer conversion efficiency to estimate the storage charging efficiency of 63%. Capital costs of the underground hydrogen storage are assumed to scale with total volumetric energy capacity and remain constant across our planning horizon at $0.35/kWh [146] (escalated to 2018$). A hydrogen combined-cycle gas turbine is modeled after a natural gas combinedcycle turbine and assumed to perform at similar LHV efficiency (53%) and cost per [94] . ...
As energy utilities implement climate change mitigation policies, system planners require strategies for achieving affordable emissions reductions. Coordinated planning of electric power and natural gas systems will allow synergistic investments to address cross-sector operational constraints, competing uses for net-zero emissions fuels, and shifts in energy demands across energy carriers. In this study, we develop a novel optimization program that finds the cost-minimizing mix of infrastructure expansion or reduction across gas and electric systems to satisfy sector-specific emissions constraints. Alongside energy supply resources, our framework allows for central-planning of end-use equipment stocks to allow switching between gas and electric appliances upon failure or premature replacement. The proposed model is used to simulate case study scenarios for a benchmark 24-pipe gas network coupled to a 24-node power system test network. We find that electrification of greater than 80% of core gas demands is a component of the least-cost solution for modeled energy systems. Despite this substitution, the gas system is maintained to service difficult-to-electrify customers and to deliver net-zero emissions gas to electricity generators in times of peak electricity demand. Restricting electrification of gas appliances increases reliance on power-to-gas technologies and increases annual costs by 15% in 2040. Neglecting constraints on pipeline blending of hydrogen can produce a misleading result that relies on hydrogen blend fractions of greater than 50%. In all cases, we find the average costs of delivered gas increase nearly 5-fold across the decarbonization transition, highlighting the importance of future work investigating cost-allocation strategies for ensuring an equitable energy transition.
... In Ref. [30] for the natural gas-fuelled Capstone C65 are given following figures e 1540 $/kW capital expenses and 10 years lifetime. Earlier synopsis for large-scale hydrogen fuelled gas turbines made by NREL [41] shows 25% growth in capital expenses compared to natural gas fired versions, so such estimations are also made for microturbines. Lifetime varies from 36 to 80 thousands of hours. ...
Hydrogen energy technologies are considered as the cutting-edge clean energy technologies all over the world. Novel concept of hydrogen energy development in Russia, proposed by Government has hydrogen technologies equipment development, production and introduction into domestic market as one of the tasks. Foreign experience shows that governmental support is very important for successful branch development. Waste hydrogen from chlorine industry utilization can be energy-efficient and attractive niche for fuel cells and hydrogen-fuelled heat engines application. Lifetime and capital costs are important parameters for technology choice decision. Energy cost and hydrogen consumption comparison were carried out for gas microturbines (MGT), fuel cells (FC) and internal combustion engines (ICE) in this paper. Analysis showed polymer electrolyte membrane fuel cells and gas microturbines to be the most promising technology in this niche while for internal combustion engines lifetime is an issue. Solid oxide fuel cells need significant capital costs decrease for successful market introduction. Solid oxide fuel cells, MGT and ICE have also additional advantage for Russian conditions due to high-potential heat production possibility.
... Similarly, the storage capacity of water in pumped storage is characterized by the maximum duration of charge which is taken to be 6 h. The conversion efficiency of electricity to hydrogen in electrolyzer and hydrogen to electricity is taken from the Ref. Steward et al. (2009). This study considers the steel tank above the ground surface for storing produced hydrogen. ...
... The cost of hydrogen system components like electrolyzer, storage tank, and the fuel cell are taken from Refs. Colbertaldo et al. (2019), Steward et al. (2009) andSandia National Laboratories (2011). ...
This study integrates grid-connected hydrogen storage and carbon capture and storage (CCS) technology in a spatially disaggregated capacity expansion model, that can explicitly characterize the operational behavior of other conventional technologies. The model is then used to assess the decarbonizing pathways of the integrated power grid of four countries: Bangladesh, Bhutan, India, and Nepal of South Asia under multiple policy scenarios. The impact of the cost associated with hydrogen system components, and with capturing, transporting, and injecting CO 2 in storage sites on the technology choices and their capacities are further evaluated through sensitivity analysis. The hydrogen storage system is effective in tapping surplus energy produced from intermittent renewables mostly in coal deficit regions for both short as well as long-term duration, but its large-scale deployment depends on electrolyzer and fuel cell cost reductions by more than 20% to compete against battery technology. In a very optimistic situation of 90% cost reduction, northern, western, southern parts of India and Bangladesh can completely decarbonize its power sector by 2050 through the installation of about 593 GW, 395 GW, 138 GW, and 120 GW of hydrogen storage tank. The storage and production profiles of hydrogen are influenced by seasonal, weather, and diurnal variations. Under limited solar PV and nuclear scenario, India should start operating CCS-based coal power plants from 2030 to meet the 80% emission reduction target and techno-economically feasible capacity requirements reach about 179 GW, 106 GW, and 35 GW by 2050 in the eastern, western, and southern parts of India respectively.
... For hydrogen storage the costs depend heavily on the sizing of the respective components. The one in this paper used an electrolyser [24], salt cavern [25], and turbine [26] with a 1 kW : 80 kWh : 1.9 kW size ratio, resulting in a slow but cheap system. ...
... As Figure 6 demonstrates energy-specific PM emissions (g/kWh) as a societal criterion was considered 0.027 (g/kWh) 60 for LNG and was assumed to be negligible (zero) for all other alternatives. 60,69,70 Tables 9 and 10 demonstrate the TOPSIS decision matrix and TOPSIS calculation, respectively. ...
The importance of sea ports in the global logistics maritime supply chain and it connectivity is increasing, as is the focus on optimizing daily operational activities and minimizing the negative impact on society. One of the most significant negative externalities for sea ports is air pollution that remain one the main concern and environmental priority for Port Authorities and Government and their strategic policies. The growth of containerization in the shipping industry stimulates the demand for infrastructure development and increased energy use. This paper strives to propose the best alternative sources of energy to transit from traditional fuel to the greener ones for two important container terminals in Italy. The analyses focus on energy consumption of the most important container terminals Voltri and La Spezia in Italy and analysed using alternative sources of energy. Based on the priorities chosen by twelve experts, the cost, societal and environmental criteria are assigned the highest weight respectively. The Fuzzy Analytic Hierarchy Process (FAHP) and the Technique for Order Performance by Similarity to Ideal Solution (TOPSIS) techniques are used, to identify the best alternative sources of energy.
... Cost (£/kW) Electrolyser 10 (Vogl et al., 2018;Schmidt et al., 2017a) 540 (in 2020) (Vogl et al., 2018;Taibi et al., 2020) Hydrogen Expansion Turbine 30 (Gandolfi et al., 2020) 800 (Department for Business, 2020a; Gandolfi et al., 2020;Steward et al., 2009) Fig. 4. Energy demands and resource flows in H-DR/EAF steelmaking for a range of scrap charges. this level of scrap utilisation would require a hydrogen production rate of 181,720 tH 2 /yr, equivalent to 697 MW. ...
The iron and steel industry is one of the world's largest industrial emitters of greenhouse gases. One promising option for decarbonising the industry is hydrogen direct reduction of iron (H-DR) with electric arc furnace (EAF) steelmaking, powered by zero carbon electricity. However, to date, little attention has been given to the energy system requirements of adopting such a highly energy-intensive process. This study integrates a newly developed long-term energy system planning tool, with a thermodynamic process model of H-DR/EAF steelmaking developed by Vogl et al. (2018), to assess the optimal combination of generation and storage technologies needed to provide a reliable supply of electricity and hydrogen. The modelling tools can be applied to any country or region and their use is demonstrated here by application to the UK iron and steel industry as a case study. It is found that the optimal energy system comprises 1.3 GW of electrolysers, 3 GW of wind power, 2.5 GW of solar, 60 MW of combined cycle gas with carbon capture, 600 GWh/600 MW of hydrogen storage, and 30 GWh/130 MW of compressed air energy storage. The hydrogen storage requirements of the industry can be significantly reduced by maintaining some dispatchable generation, for example from 600 GWh with no restriction on dispatchable generation to 140 GWh if 20% of electricity demand is met using dispatchable generation. The marginal abatement costs of a switch to hydrogen-based steelmaking are projected to be less than carbon price forecasts within 5–10 years.
